Method for using neutron interaction cross section to interpret neutron measurements

ABSTRACT

A method for determining a fractional volume of at least one component of a formation includes entering into a computer a number of detected radiation events resulting from imparting neutrons into the formation at an energy level of at least 1 million electron volts (MeV). The detected radiation events correspond to at least one of an energy level of the imparted neutrons and thermal or epithermal energy neutrons. A measurement of at least one additional petrophysical parameter of the formation is made. The at least one additional petrophysical parameter measurement and at least one of a fast neutron cross-section and a thermal neutron cross-section determined from the detected radiation events are used in the computer to determine the fractional volume of the at least one component of the formation. In another embodiment, the fast neutron cross-section and the thermal neutron cross-section may be used on combination to determine the fractional volume.

CROSS-REFERENCE TO RELATED APPLICATIONS

Not Applicable.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not applicable.

NAMES TO THE PARTIES TO A JOINT RESEARCH AGREEMENT

Not Applicable.

BACKGROUND

This disclosure is related to the field of neutron well loggingmeasurements for determining petrophysical properties of subsurfaceformations traversed by a wellbore. More specifically, the disclosurerelates to using various neutron cross section values determined fromneutron measurements to determine one or more petrophysical parametersof such formations.

Various neutron based measurements have been used to evaluatecharacteristics of subsurface formations from a wellbore since at leastthe 1950s. Neutrons can interact with subsurface formations in differentways. They can be scattered elastically, which means kinetic energy andmomentum are conserved; they can be scattered inelastically, which meanscertain nuclei go into an excited state while kinetic energy is lost;they can also be captured by a nucleus to form a new nucleus; it is alsopossible that the neutron interaction causes a nuclear reactionresulting in the emission of one or more nucleons from the targetnucleus. The probability of a neutron interacting with a nucleus ismeasured by the respective interaction cross section, which is afunction of many parameters, such as incident neutron energy, outgoingneutron energy (if a neutron emerges from the interaction), scatteringangle, interaction type and interactive nucleus type, among others.Thus, neutrons can enable measurement of many different formationproperties due to the variety and complexity of their interactions.

An important wellbore neutron measurement known in the art is thethermal neutron die-away measurement. This is a measure of how fastthermal neutrons disappear. If the rate of disappearance (“decay”) isapproximated by an exponential function then the decay exponent (“decayconstant”) can be used to directly determine the formation thermalneutron capture cross section. In the oil and gas industry themacroscopic neutron capture cross section of the formation is called“sigma”. Typically this cross section is measured in capture units(c.u.), where 1 capture unit is equal to 1000 cm⁻¹.

Another important wellbore neutron measurement known in the art is theneutron porosity measurement. The basic principle of such measurement isto impart high energy neutrons (typically several MeV depending on thesource type) into the formation and measure the thermal (or epithermal)neutron flux at a certain distance from the source. The detector can beeither a neutron detector or a gamma ray detector (measuring neutroninduced gamma rays as an indirect measurement of the neutron flux). Thismeasurement is very sensitive to the hydrogen content in the formationbecause hydrogen is the most effective neutron moderator among allelements. High hydrogen content can slow down neutrons to thermal energy(0.025 eV at room temperature) before they can travel very far. Thus, HI(Hydrogen Index) and porosity (fresh water filled) may be used tointerpret the measurement. A limitation of the neutron porositymeasurement is that it is accurate only for water filled, clean (clayfree) single lithology (such as sandstone, limestone and dolomite)formations. Some other environmental conditions need special treatment,such as gas-filled porosity, shale, and complex lithology. In addition,the thermal neutron porosity measurement is sensitive to variousenvironment effects including temperature and borehole and formationsalinity.

Slowing-Down Length (Ls) is a parameter that describes how far a fastneutron travels on average before it is slowed down to thermal energy.It has been used in the past to interpret the neutron porositymeasurement as well. The tool response can be predicted accurately, butthe limitation is that Ls does not follow a volumetric mixing law. Thus,this technique is not widely used by petrophysicists.

SUMMARY

One aspect of the disclosure relates to a method for determining afractional volume of at least one component of a formation. Methodsaccording to this aspect of the disclosure include entering into acomputer a number of detected radiation events resulting from impartingneutrons into the formation at an energy level of at least 1 millionelectron volts (MeV). The detected radiation events correspond to atleast one of an energy level of the imparted neutrons, and thermal orepithermal energy neutrons. A method according to the present aspect ofthe disclosure includes at least one of, (i) using a fast neutroncross-section and a thermal neutron cross-section determined from thedetected radiation events to determine a fractional volume of the atleast one component of the formation, and (ii) using a measurement of atleast one additional petrophysical parameter and using (a) themeasurement of the at least one petrophysical parameters and (b) atleast one of the fast neutron cross-section and the thermal neutroncross-section t determine the fractional volume of the at least onecomponent of the formation.

Other aspects and advantages will be apparent from the description andclaims that follow.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1A shows an example well logging instrument conveyed through awellbore by an electrical cable (“wireline”).

FIG. 1B shows an example logging while drilling instrument on a drillstring.

FIG. 1C shows an example computer system that may be used in someimplementations.

FIG. 1D shows a schematic representation of an example dual detectorneutron well logging instrument.

FIGS. 2A through 2D show fundamental neutron microscopic cross sectionsas a function of energy for common earth elements.

FIG. 3 shows a cross plot of neutron elastic scattering cross section(cm⁻¹) at thermal neutron energy and a 1-eV neutron energy for differentlithologies and porosities.

FIG. 4 shows a graph of moderating power (cm⁻¹) with respect to thermalneutron elastic scattering cross section (cm⁻¹).

FIG. 5 shows a graph of neutron slowing down length (cm) vs. thermalneutron elastic scattering cross section (cm⁻¹).

FIG. 6 shows a graph of CNT thermal neutron detector ratio as a functionof the macroscopic thermal neutron elastic scattering cross section.

FIG. 7 shows a graph of CNT epithermal neutron detector ratio as afunction of the macroscopic thermal neutron elastic scattering crosssection.

FIG. 8 shows a graph of pulsed neutron logging tool thermal detectorratio with respect to thermal neutron elastic scattering cross section.

FIG. 9 shows a graph indicating how pulsed neutron logging tool detectorthermal ratio can be predicted accurately by a function of thermalneutron elastic scattering cross section, bulk density and sigma.

FIG. 10 shows a graph of pulsed neutron logging instrument inelasticmeasurement with respect to 14 MeV neutron elastic scattering crosssection.

FIG. 11 shows a graph of how pulsed neutron logging tool inelasticmeasurements can be predicted accurately by a function of the 14 MeVneutron elastic scattering cross section, bulk density and sigma.

FIG. 12 shows a graph of modeled thermal neutron detector count rateratio measured in a conventional, open hole compensated neutron porositytool at laboratory conditions as a function of the parameter TNXS with acorrection for thermal neutron capture cross section, Sigma.

FIG. 13 shows a graph of modeled inelastic gamma ray events in a gammaray detector of a typical pulsed neutron well logging instrument as afunction of the 14-MeV neutron macroscopic elastic scattering crosssection.

FIG. 14 shows a graph of modeled inelastic gamma ray events in a gammaray detector of a typical pulsed neutron logging tool as a function ofthe parameter FNXS.

FIG. 15 shows a flow chart of an example process to obtain FNXS.

FIG. 16 shows a flow chart of an example process to obtain TNXS.

FIG. 17 shows a flow chart of an example process to determine formationparameters using FNXS or TNXS.

DETAILED DESCRIPTION

FIG. 1A shows an example well logging instrument 30. The measurementcomponents of the instrument 30 may be disposed in a housing 111 shapedand sealed to be moved along the interior of a wellbore 32. Theinstrument housing 111 may contain at least one energy source 115, e.g.,a neutron source such as electrically operated pulsed neutron source(“source”), and one or more detectors 116, 117 each disposed atdifferent axial spacings from the source 115. The source 115 may emitneutron radiation. Shielding (not shown) may be applied between thesource 115 and the detectors 116, 117 to reduce direct transmission ofneutrons from the source 115 to the detectors 116, 117. Thus, detectedradiation may be characterized at each of a plurality of distances fromthe source 115, and thus have different lateral response (depth ofinvestigation) into the formations surrounding the wellbore 32. In someexamples, two or more different types of well logging instrument, eachhaving a different type of source and different types of correspondingdetectors may be included in the same instrument assembly of “toolstring.”

The instrument housing 111 maybe coupled to an armored electrical cable33 that may be extended into and retracted from the wellbore 32. Thewellbore 32 may or may not include metal pipe or casing 16 therein. Thecable 33 conducts electrical power to operate the instrument 30 from asurface 31 deployed recording system 70, and signals from the detectors116, 117 may be processed by suitable circuitry 118A for transmissionalong the cable 33 to the recording system 70. The recording system 70may include a processor, computer or computer system as will beexplained below with reference to FIG. 1C for analysis of the detectedsignals as well as devices for recording the signals communicated alongthe cable 33 from the instrument 30 with respect to depth and/or time.

The well logging tool described above can also be used, for example, inlogging-while-drilling (“LWD”) equipment. As shown, for example, in FIG.1B, a platform and derrick 210 are positioned over a wellbore 212 thatmay be formed in the Earth by rotary drilling. A drill string 214 may besuspended within the borehole and may include a drill bit 216 attachedthereto and rotated by a rotary table 218 (energized by means not shown)which engages a kelly 220 at the upper end of the drill string 214. Thedrill string 214 is typically suspended from a hook 222 attached to atraveling block (not shown). The kelly 220 may be connected to the hook222 through a rotary swivel 224 which permits rotation of the drillstring 214 relative to the hook 222. Alternatively, the drill string 214and drill bit 216 may be rotated from the surface by a “top drive” typeof drilling rig.

Drilling fluid or mud 226 is contained in a mud pit 228 adjacent to thederrick 210. A pump 230 pumps the drilling fluid 226 into the drillstring 214 via a port in the swivel 224 to flow downward (as indicatedby the flow arrow 232) through the center of the drill string 214. Thedrilling fluid exits the drill string via ports in the drill bit 216 andthen circulates upward in the annular space between the outside of thedrill string 214 and the wall of the wellbore 212, as indicated by theflow arrows 234. The drilling fluid 226 thereby lubricates the bit andcarries formation cuttings to the surface of the earth. At the surface,the drilling fluid is returned to the mud pit 228 for recirculation. Ifdesired, a directional drilling assembly (not shown) could also beemployed.

A bottom hole assembly (“BHA”) 236 may be mounted within the drillstring 214, preferably near the drill bit 216. The BHA 236 may includesubassemblies for making measurements, processing and storinginformation and for communicating with the Earth's surface. Suchmeasurements may correspond to those made using the instrument stringexplained above with reference to FIG. 1A. The bottom hole assembly istypically located within several drill collar lengths of the drill bit216. In the illustrated BHA 236, a stabilizer collar section 238 isshown disposed immediately above the drill bit 216, followed in theupward direction by a drill collar section 240, another stabilizercollar section 242 and another drill collar section 244. Thisarrangement of drill collar sections and stabilizer collar sections isillustrative only, and other arrangements of components in anyimplementation of the BHA 236 may be used. The need for or desirabilityof the stabilizer collars will depend on drilling conditions as well ason the demands of the measurement.

In the arrangement shown in FIG. 1B, the components of the well logginginstrument may be located in the drill collar section 240 above thestabilizer collar 238. Such components could, if desired, be locatedcloser to or farther from the drill bit 216, such as, for example, ineither stabilizer collar section 238 or 242 or the drill collar section244.

The BHA 236 may also include a telemetry subassembly (not shown) fordata and control communication with the Earth's surface. Such telemetrysubassembly may be of any suitable type, e.g., a mud pulse (pressure oracoustic) telemetry system, wired drill pipe, etc., which receivesoutput signals from LWD measuring instruments in the BHA 236 (includingthe one or more radiation detectors) and transmits encoded signalsrepresentative of such outputs to the surface where the signals aredetected, decoded in a receiver subsystem 246, and applied to aprocessor 248 and/or a recorder 250. The processor 248 may comprise, forexample, a suitably programmed general or special purpose processor. Asurface transmitter subsystem 252 may also be provided for establishingdownward communication with the bottom hole assembly.

The BHA 236 can also include conventional acquisition and processingelectronics (not shown) comprising a microprocessor system (withassociated memory, clock and timing circuitry, and interface circuitry)capable of timing the operation of the accelerator and the datameasuring sensors, storing data from the measuring sensors, processingthe data and storing the results, and coupling any desired portion ofthe data to the telemetry components for transmission to the surface.The data may also be stored in the instrument and retrieved at thesurface upon removal of the drill string. Power for the LWDinstrumentation may be provided by battery or, as known in the art, by aturbine generator disposed in the BHA 236 and powered by the flow ofdrilling fluid. The LWD instrumentation may also include directionalsensors (not shown separately) that make measurements of the geomagneticorientation or geodetic orientation of the BHA 236 and the gravitationalorientation of the BHA 236, both rotationally and axially.

The foregoing computations may be performed on a computer system such asone shown in the processor at 248 in FIG. 1B, or in the surface unit 70in FIG. 1A. However, any computer or computers may be used to equaleffect.

FIG. 1C shows an example computing system 100 in accordance with someembodiments for carrying out example methods such as those to beexplained below with reference to FIGS. 2 through 11. The computingsystem 100 can be an individual computer system 101A or an arrangementof distributed computer systems. The computer system 101A includes oneor more analysis modules 102 that are configured to perform varioustasks according to some embodiments, such as the tasks described above.To perform these various tasks, an analysis module 102 executesindependently, or in coordination with, one or more processors 104,which is (or are) connected to one or more storage media 106. Theprocessor(s) 104 is (or are) also connected to a network interface 108to allow the computer system 101A to communicate over a data network 110with one or more additional computer systems and/or computing systems,such as 101B, 101C, and/or 101D (note that computer systems 101B, 101Cand/or 101D may or may not share the same architecture as computersystem 101A, and may be located in different physical locations, e.g.computer systems 101A and 101B may be on a ship underway on the ocean,in a well logging unit disposed proximate a wellbore drilling, while incommunication with one or more computer systems such as 101C and/or 101Dthat are located in one or more data centers on shore, other ships,and/or located in varying countries on different continents). Any one ormore of the computer systems may be disposed in the well logginginstrument (whether wireline as in FIG. 1A or LWD as in FIG. 1B).

A processor can include a microprocessor, microcontroller, processormodule or subsystem, programmable integrated circuit, programmable gatearray, digital signal processor (DSP), or another control or computingdevice.

The storage media 106 can be implemented as one or more non-transitorycomputer-readable or machine-readable storage media. Note that while inthe embodiment of FIG. 1C storage media 106 is depicted as withincomputer system 101A, in some embodiments, storage media 106 may bedistributed within and/or across multiple internal and/or externalenclosures of computing system 101A and/or additional computing systems.Storage media 106 may include one or more different forms of memoryincluding semiconductor memory devices such as dynamic or static randomaccess memories (DRAMs or SRAMs), erasable and programmable read-onlymemories (EPROMs), electrically erasable and programmable read-onlymemories (EEPROMs) and flash memories; magnetic disks such as fixed,floppy and removable disks; other magnetic media including tape; opticalmedia such as compact disks (CDs) or digital video disks (DVDs); orother types of storage devices. Note that the instructions discussedabove can be provided on one computer-readable or machine-readablestorage medium, or alternatively, can be provided on multiplecomputer-readable or machine-readable storage media distributed in alarge system having possibly plural nodes. Such computer-readable ormachine-readable storage medium or media is (are) considered to be partof an article (or article of manufacture). An article or article ofmanufacture can refer to any manufactured single component or multiplecomponents. The storage medium or media can be located either in themachine running the machine-readable instructions, or located at aremote site from which machine-readable instructions can be downloadedover a network for execution.

It should be appreciated that computing system 100 is only one exampleof a computing system, and that computing system 100 may have more orfewer components than shown, may combine additional components notdepicted in the embodiment of FIG. 1C, and/or computing system 100 mayhave a different configuration or arrangement of the components depictedin FIG. 1C. The various components shown in FIG. 1C may be implementedin hardware, software, or a combination of both hardware and software,including one or more signal processing and/or application specificintegrated circuits.

Further, the steps in the methods described above may be implemented byrunning one or more functional modules in information processingapparatus such as general purpose processors or application specificchips, such as ASICs, FPGAs, PLDs, SOCs, or other appropriate devices.These modules, combinations of these modules, and/or their combinationwith general hardware are all included within the scope of protection ofthe invention.

FIG. 1D shows a schematic cross section of an example neutron welllogging instrument structure. Three detectors 116, 117, 118 at variouslongitudinal spacings from a neutron source 115 are indicated, but forsome embodiments a single detector may suffice. The detectors 116, 117,118 may be fast neutron detectors, thermal neutron detectors, epithermalneutron detectors, gamma ray detectors, or combinations thereof. Theforegoing may also include detectors which are sensitive to bothneutrons and gamma rays, in which the neutron and gamma ray detectionevents can be distinguished. Shielding 119 between the source and thedetectors reduces or prevents the direct passage of radiation from theneutron source to the detectors 116, 117 and 118. The neutron source 115may be a radioisotope source, such as ²⁴¹AmBe or ²⁵²Cf, or a pulsedneutron generator. The pulsed neutron generator may be based on thedeuterium-tritium reaction (with source energy of 14.1 MeV, thedeuterium-deuterium reaction (with a source energy of about 2.45 MeV) orany other suitable reaction. Methods according to the present disclosurecan be applied to any form of neutron logging tools with the abovedescribed detector and/or neutron source options.

FIGS. 2A through 2D show the basic neutron microscopic cross sections ofa few common earth elements, i.e., hydrogen, carbon, oxygen and silicon,respectively. In terms of neutron well logging applications, the mostrelevant neutron interaction types with formation materials are elasticscattering, inelastic scattering, and neutron capture, which are shownin FIGS. 2A through 2D. The x-axis indicates the incident neutronenergy, ranging from thermal (0.025 eV) to 20 MeV on a logarithmicscale. The foregoing range covers substantially all neutron energylevels used in neutron well logging methods known in the art. The y-axisrepresents the neutron microscopic cross section on a logarithmic scale,with units of barns per atom. As can be observed in FIGS. 2A through 2D,all the three neutron cross sections, i.e., inelastic scattering shownrespectively at curves 123A, 125A and 127A (in FIGS. 2B, 2C and 2D,respectively), elastic scattering shown at curves 121, 123, 125 and 127and capture at curves 122, 124, 126 and 128 all vary as a function ofincident neutron energy.

The capture cross section is typically low for neutrons at the millionelectron volt (MeV) energy level and above. The multiple peaks (forexample, 0.05 to 1 MeV region in FIG. 2D) observable in FIGS. 2B, 2C and2D are resonance peaks. The resonance energies are determined by theavailable excited states of nuclei with a certain number of protons andneutrons. Generally speaking, a heavier nucleus (with many protons andneutrons) will have lower resonance energies, and vice versa. Theextreme example is the hydrogen nucleus, which has only a ground statewith one proton and no neutron, so there is no resonance peak. Below theresonance energy region, the capture cross section typically increasesproportionally to 1/v, where v is the neutron velocity. For a thermalneutron die-away measurement (equivalent to a thermal neutron capturecross section or “sigma” measurement), source neutrons with originalenergy in a range of a few MeV to more than about ten MeV will be sloweddown very quickly to thermal energy and reach an equilibrium state. Thecapture cross section at thermal energy is typically a few orders ofmagnitude higher than at higher energy. The chance of a neutron beingcaptured before it reaches thermal equilibrium is therefore very low.Because of this fact, the capture cross section at thermal energy isused in neutron sigma measurement well logging known in the art tointerpret the thermal neutron die-away measurement. Following the sameprinciple, methods according to the present disclosure expand theforegoing concept to other types of neutron interaction cross sections.

For a neutron porosity measurement, the source neutrons are slowed downpartially through elastic scattering and partially through inelasticscattering from the initial source energy (above 1 MeV) all the way tothermal energy. The elastic/inelastic scattering cross sections in allthe energy levels from the source energy to thermal energy are part ofthis process. Thus, it may be difficult to pick just one quantity orvalue to interpret the measurement. By further analyzing the crosssection data, one can observe that elastic scattering has a largereffect on neutron energy reduction than inelastic scattering. This isbecause of the relative number of inelastic and elastic scatteringevents. Although a neutron can lose a lot of energy (˜MeV) by a singleinelastic scattering interaction, this can only occur at high neutronenergy levels (typically >1 MeV). Below the 1-MeV energy threshold,inelastic scattering substantially does not occur. Thus, in its lifetimefrom emission by the source to reduction to thermal energy a neutron mayonly have a single inelastic scattering event. On the other hand,elastic scattering can occur at any energy and its probability istherefore a lot higher than for inelastic scattering. As a first orderapproximation, one can pick the elastic cross section as the variable tointerpret a neutron porosity measurement. One step further, if oneobserves the elastic cross section carefully, one may notice that belowa certain energy level, the elastic cross section is no longer afunction of neutron energy. For example, below 0.05 MeV and above 1 eV,the hydrogen elastic cross section (FIG. 2A) is constant. It startsincreasing again below 1 eV as energy decreases. This is because elasticscattering in this energy region is just like billiard ball scatteringin classical physics; the probability is independent of the incidentvelocity. Below 1 eV, the neutron energy is close to the energy of thethermal movement of atoms. Fortuitously for purposes of methodsaccording to the present disclosure, most of the scattering events forneutron slowing down occur in the energy region from 1 eV to 0.05 MeV.Thus, methods according to the present disclosure may use this energyindependent elastic scattering cross section to interpret neutronporosity measurements. There are some approximations in such methods.Methods according to the present disclosure may neglect inelasticscattering, resonance scattering, and the variation of the elasticscattering cross section above about 0.05 MeV. Thus, one may or may notneed to use other quantities, such as bulk density, to improve theaccuracy of the interpreted measurements.

In order to take the neutron energy loss per scattering event intoaccount, one can also use the “moderating power”, which is sometimescalled “slowing down power”, to interpret the neutron porositymeasurement. The concept of moderating power is commonly used in nuclearreactor physics. One can find more details in, Duderstadt, James J,“Nuclear Reactor Analysis”, ISBN 0-471-22363-8.

ModeratingPower=ξ—Σ_(s)  (1)

The definition of Moderating Power (MP) is shown in Eq. 1, where ξ isthe mean lethargy gain per neutron collision, and Σ_(s) is themacroscopic elastic scattering cross section. Lethargy, which is ameasure of the relative energy loss, is defined in Eq. 2 below.

$\begin{matrix}{\xi = {1 - {\frac{\left( {A - 1} \right)^{2}}{2\; A} \cdot {\ln \left( \frac{A + 1}{A - 1} \right)}}}} & (2)\end{matrix}$

where A is the atomic mass.

Thus,

$\begin{matrix}\begin{matrix}{{MP} = {\xi \cdot \Sigma_{s}}} \\{= {\left\lbrack {1 - {\frac{\left( {A - 1} \right)^{2}}{2\; A} \cdot {\ln \left( \frac{A + 1}{A - 1} \right)}}} \right\rbrack \cdot \Sigma_{s}}}\end{matrix} & (3)\end{matrix}$

MP is in effect a weighted scattering cross section, with the weightbeing a function of the atomic mass of the scattering nucleus. MPfollows a volumetric mixing law.

Eq. 4 shows one way to compute the macroscopic cross section frommicroscopic cross section for any element. Σ is the macroscopic crosssection; σ is the microscopic cross section; ρ is the bulk density; A isthe atomic mass; and N_(a) is Avogadro's constant (approximately6.02×10²³ mol⁻¹). For a material containing more than one element, Eq. 5may be used to combine the macroscopic cross sections of multipleelements. Σ_(total) is the material's macroscopic cross section; Σ_(i)is the i^(th) element's macroscopic cross section; ƒ_(i) is the volumefraction of the i^(th) element; N is the total number of elements. Thus,the macroscopic cross section follows a volumetric mixing law as shownin Eq. 5.

$\begin{matrix}\begin{matrix}{\Sigma = {\sigma \cdot {AtomDensity}}} \\{= {\sigma \cdot \frac{\rho}{A} \cdot N_{a}}}\end{matrix} & (4) \\{\Sigma_{total} = {\sum\limits_{i = {1\text{:}N}}\; \left( {f_{i} \cdot \Sigma_{i}} \right)}} & (5)\end{matrix}$

FIG. 3 shows a graph of the correlation between the macroscopic neutronelastic scattering cross sections at two different neutron energies, 1eV and thermal energy (0.025 eV at 25° C.). Although the elastic crosssection values are different at each energy level, they are almost 100%correlated and will be so for many different formation conditions. Thus,one can choose to use either of the elastic scattering cross sections at1 eV or at thermal energy to predict a neutron tool response. In thepresent embodiment of the disclosure, the neutron elastic scatteringcross section at thermal energy may be used to demonstrate the examplemethod.

FIG. 4 shows a graph of the correlation between the neutron elasticscattering cross section and the moderating power at thermal energy.There are many different formation conditions shown in FIG. 4, includingrock mineralogy including sandstone, limestone, dolomite and variouswater filled porosities (0 percent porosity (“p.u.”) to 100 p.u.), andsome other lithologies like halite, illite and anhydrite. FIG. 4 shows astrong correlation between the moderating power and the elasticscattering cross section at thermal energy. However, not all theforegoing conditions fall precisely on the same line. For 0-p.u.sandstone, limestone, dolomite and halite, the moderation power andelastic cross section have slightly different behavior. It has beendetermined empirically that the elastic cross section is more accuratein predicting a neutron logging tool response than the moderating power.However, either of them may be used for purposes of methods according tothe present disclosure.

FIG. 5 shows the correlation between the thermal neutron elasticscattering cross section and the neutron slowing down length (from 14MeV down to thermal energy). One can use the elastic cross section todetermine the slowing down length in most conditions based on thecorrelation shown in FIG. 5. There are several exceptional conditions.The computation of the slowing down length uses neutron capture crosssection, which varies from 14 MeV to thermal energy, in addition to theelastic cross sections. The resonance integral is an importantconsideration in capturing a neutron during its slowing down. Sigma,which is the neutron capture cross section at the thermal energy, may ormay not correlate with the resonance integral. However, one can stilluse sigma in addition to the elastic cross section to determine theslowing down length more accurately. The porosities in FIG. 5 are 0p.u., 2.5 p.u., 5 p.u., 10 p.u., 20 p.u., 40 p.u., 60 p.u., and 100 p.u.Another exception is in the high porosity region (>40 p.u.). From 40p.u. to 100 p.u., the slowing down length does not change much but theelastic cross section increases linearly as the porosity increases. Thisphenomenon may be described as the slowing down length saturating athigh porosity. The porosity value at which saturation begins depends onthe neutron source energy. With an AmBe neutron source with averageemitted neutron energy around 4 MeV, the slowing down length does notsaturate at high porosity. For the conversion of 14 MeV slowing downlength to AmBe slowing down length the formation density can be used tohelp with the conversion as more fully described in U.S. Pat. No.7,667,192 issued to Fricke et al. Thus, the use of the formation bulkdensity in addition to neutron cross sections can help to predict theneutron tool response more accurately, especially at high porosity.

A fast neutron measurement is possible based on fast neutron detectors.The energy of a fast neutron is typically in the MeV range. There aretwo ways in which to measure fast neutrons. One is the directmeasurement, which uses a fast neutron detector; the other is anindirect measurement, which measures the fast neutron induced gammarays. Fast neutrons can induce gamma rays through inelastic neutronscattering (n, n′y) or a neutron reaction such as (n, p) or (n, alpha),and other reactions which have an energy threshold for their productionin the MeV range. Among all reaction types inducing gamma rays, theinelastic scattering is the predominant one. In principle, the fastneutron measurement measures how strongly the fast neutrons areattenuated by the formation. Beside the reactions that can induce gammarays, elastic scattering can also attenuate fast neutrons. It can slowdown fast neutrons or scatter them away. There are many choices of crosssections, which can be used to interpret a fast neutron measurement. Onecan choose to use the total, elastic, or inelastic cross sections, orany form of linear combination of the foregoing at the neutron sourceenergy. Instead of using the cross section at a single energy level, onecan use integrated cross sections over a certain neutron energy range.In this disclosure, the elastic cross section at the source energy maybe used to demonstrate the example method.

FIG. 6 shows the thermal neutron detector count rate ratios measured bya two-detector thermal neutron instrument using an AmBe radioisotopesource. One example of such an instrument is sold under the trademarkCNT, which is a trademark of Schlumberger Technology Corporation, SugarLand, Tex. The CNT well logging tool for purposes of evaluating methodsaccording to the present disclosure was operated in laboratoryconditions including a number of different formation tanks, includingthree lithologies (sandstone, limestone and dolomite) with various freshwater filled porosities (from 0 p.u. to 100 p.u.). The solid line inFIG. 6 represents a polynomial fit through all the data points. Thethree different lithologies appear to be on the same curve. One mayconclude that the thermal elastic cross section can represent what thetool measures independent of the lithology. In case of salty waterfilling the pore space of such formations, sigma measurements may beused additionally to predict the tool response. Sigma may be measuredusing many types of pulsed neutron logging instruments known in the art.

FIG. 7 shows the epithermal neutron detector count rate ratios measuredby a modified version of the CNT instrument in the laboratory as afunction of the macroscopic thermal neutron elastic cross section. Themodified CNT is equipped with a cadmium filter around the two neutrondetectors to suppress detection of thermal neutrons and letsubstantially only epithermal neutrons pass through to the detectors.There may be a number of different formation tanks, including, e.g.,three lithologies (sandstone, limestone and dolomite) with various freshwater filled porosities (from 0 p.u. to 100 p.u.). The solid linerepresents a polynomial fit through all the data points. Similar to thethermal ratio (FIG. 6), the count rate ratios for the three differentlithologies stay on the same curve. Thus, the same principle can beapplied to epithermal count rate ratios measured by such a well logginginstrument. Another way to measure neutron porosity using an epithermalneutron detector is the slowing down time (SDT) measurement, whichrequires a pulsed neutron generator as a source and measuring anepithermal neutron count rate as a function of time (epithermal neutrondie-away). The SDT measurement can also be interpreted using themacroscopic thermal neutron elastic cross section in a way similar tothat discussed above. Sigma may (or may not) be used additional to themacroscopic thermal neutron elastic cross section to interpret the SDTmeasurement to improve the accuracy.

FIG. 8 shows modeling results based on a pulsed neutron logging toolwith two gamma ray detectors. The thermal neutron induced capture gammarays are measured in the detectors after the end of each neutron burst.The ratios of the two detector count rates are plotted against thethermal neutron elastic cross section. The formation conditions includesandstone, limestone, dolomite with various fresh and salty waterporosities (0, 2.5, 5, 10, 20, 40, 60, and 100 p.u.), 10-p.u. methane(CH₄) filled porous sandstone, 0-p.u. anhydrite, and illite. Thewellbore condition is a fresh-water filled open hole (6-in bit size). Atlow porosity (cross section is lower than 0.5 l/cm), the threelithologies (sandstone, limestone, and dolomite) can all be describedwell by the thermal elastic cross section. Sigma and densitymeasurements may be required to predict the instrument response in morecomplex conditions.

The data points in FIG. 9 are taken at the same conditions as the onesin FIG. 8. A forward model has been developed to predict the detectorratios based on three formation quantities, bulk density, sigma andthermal elastic cross section. FIG. 9 shows the modeled detector countrate ratio versus the forward model prediction ƒ. The predictions agreewith the data very well. This forward model is a second order polynomialfunction of the foregoing three quantities. There are other possibleformulas that can be used.

As a practical matter, bulk density and sigma can be measured using wellknown logging instruments. Thus, one can derive the formation thermalelastic cross section from any neutron porosity tool. Then one mayderive the porosity or saturation from it, in a manner similar to thatused with bulk density measurements.

The data points in FIG. 10 are taken at the same conditions as the onesin FIG. 8. The y-axis in FIG. 10 is an inelastic gamma ray measurement,which is obtained using a pulsed neutron well logging tool having a14-MeV source and a gamma ray detector. The measurement is essentiallythe inelastic gamma ray (fast neutron induced gamma rays from inelasticscattering) count rate measured in the detector. It can be obtained byremoving the capture gamma ray (thermal neutron induced gamma rays fromcapture) count rate from the gamma ray count rate measured during thesource neutron burst, which contains both inelastic and capture gammarays. There are other ways to obtain an inelastic measurement known inthe art. The y-axis in FIG. 10 is this inelastic measurement divided bya neutron output measurement from a fast neutron monitor to remove theneutron generator output variation. Since only fast neutrons with energyabove a certain threshold (typically above the 1-MeV level) can induce agamma ray inelastically, theoretically an inelastic measurement is onlysensitive to fast neutrons with energy approximately in the 1 MeV andabove range. The x-axis in FIG. 10 is the neutron elastic cross sectionat 14 MeV, which is the neutron source energy of a d-T generator. Theinelastic measurement is more sensitive to gas-filled porosity than towater-filled porosity. The highest value in the inelastic measurementcorresponds to 10 p.u. CH₄ (density 0.15 g/cm³)-filled sandstone. Theinelastic measurement also has a lithology dependence: sandstone ishigher than limestone, which is higher than dolomite. The 14-MeV elasticcross section describes qualitatively the behavior of the inelasticmeasurement. Other formation quantities, such as bulk density, may berequired to predict the inelastic response more accurately, as in theexample shown below.

The inelastic gamma ray measurement discussed above is based on a singledetector with a pulsed neutron generator as a source. As a practicalmatter, the output of a pulsed neutron generator can vary over time.Thus, the single detector measurement may need to be normalized (e.g.,divided by) a neutron generator output measurement in a real time to befree of neutron output variation. Such a neutron output measurement canbe obtained directly using a fast neutron detector located with respectto the neutron generator so as to have response substantially onlyrelated to generator output, or indirectly from the neutron generatoroperation parameters.

The data points in FIG. 11 are taken at the same conditions as the onesin FIG. 8. A forward model has been developed to predict the inelasticmeasurement count rate based on three formation quantities, sigma,14-MeV elastic cross section and bulk density. FIG. 11 shows theinelastic measurement versus the forward model prediction. The formulais a second order polynomial of the foregoing three formationquantities. The prediction is quite accurate. The 0-p.u. anhydrite and100-p.u. water predictions are less precise than other formationconditions. Sigma and bulk density may be measured using well knownlogging instruments as explained above. When such measurements areavailable, one can derive the 14 MeV elastic cross section from a pulsedneutron tool. Depending on the application, one can use other formulasto predict the tool response. One can also choose not to use the bulkdensity but only sigma and the 14-MeV elastic cross section to predictthe tool response (albeit with somewhat reduced accuracy).

TABLE 1 Neutron cross section values of a few typical formation matrixmaterials and formation fluids Macroscopic Macroscopic neutron elasticneutron elastic scattering cross section at scattering cross section atMaterial thermal energy (1/cm) 14-MeV energy (1/cm) Sandstone 0.26510.0684 Limestone 0.3242 0.0751 Dolomite 0.3762 0.0851 Fresh Water 2.14780.0780 CH4 (0.15 g/cm3) 0.7066 0.0201 Diesel 2.3296 0.0785 Wet Illite0.9516 0.0802

Table 1 lists neutron elastic scattering cross sections of some typicalformation matrix materials and fluids. In terms of thermal elastic crosssections, the three principal matrix materials (lithologies) havedifferent values but are generally within a small range, while thevalues of water and oil are similar and substantially higher than thethree lithologies. The values of gas and clay are higher than the threelithology values but lower than water and oil due to the difference inhydrogen content. Thus, the thermal elastic scattering cross section isa measurement, which is very sensitive to the presence of water or oil,may not be able to differentiate water from oil, has different lithologyeffects, and is sensitive to gas and clay. The thermal elasticscattering cross section has a different interpretation than otherwell-known neutron porosity measurements.

The 14-MeV elastic scattering cross section is a quantity which is notknown to be used in the petroleum industry. The values for the threeclean lithologies, fresh water, oil, and clay are different but verysimilar. The only outlier is gas, which is factor 3 to 4 times smallerthan the others. Thus, this quantity is very sensitive to the presenceof gas in the formation, and still has a small lithology andwater-filled porosity effect. This measurement can be used to quantifygas-filled porosity and gas-saturation.

After extracting the neutron elastic cross sections at thermal energyand 14-MeV energy from a neutron logging tool, one can use one of them(or both) to solve for petrophysical parameters such as porosity, fluidsaturation, and so on. In the meantime, one can also combine the twonewly defined neutron cross sections with other measurements, such asbulk density, sigma, natural gamma ray, resistivity, and so on to solvemore complex problems.

Below are examples of applications based on the two above definedneutron cross sections. A well logging instrument, such as explainedwith reference to FIG. 1D may emit neutrons (at least 1 MeV) intoformations surrounding a wellbore. Radiation events, such as inelasticgamma rays, fast neutrons, epithermal neutrons, thermal neutrons andcapture gamma rays may be measured at at least two differentlongitudinal distances from the point of neutron emission. For example,if thermal neutrons or epithermal neutrons are detected, a measuredcount rate or a ratio of two measured count rates taken from detectorsat different spacings from the source may be used to determine thethermal neutron elastic scattering cross-section. If high energyneutrons or resulting gamma rays are detected, a measured count rate ora ratio of two measured count rates as above may be used, in someexamples in combination with a measurement of bulk density or sigma, todetermine the high energy neutron elastic scattering cross-section. Apulsed neutron instrument with suitable detectors may be used in someexamples of the foregoing, to determine the high energy neutron elasticscattering cross section and sigma (by detecting thermal neutron capturegamma rays or thermal neutrons).

The formation typically contains the rock matrix and pore space, whichcan be filled with fluid (oil, water, or salty water) or gas, or a mixof them. The formation cross section Σ_(total) can be written asindicated in Eq. 6, Eq. 7 or Eq. 8 shown below depending on theavailable knowledge or assumptions. This is very similar to anyderivation of a petrophysical property that follows a known mixing law,e.g., a linear volumetric mixing law. In the present disclosure areintroduced two independent neutron cross sections, which are the thermalneutron elastic scattering cross section and the 14-MeV neutron elasticscattering cross section.

Depending on the logging tool used, different neutron cross sections canbe measured. For example, the CNT (compensated neutron tool) welllogging instrument cannot measure sigma or the 14-MeV neutron elasticcross section, but may be able to measure the thermal neutron elasticscattering cross section. Pulsed neutron logging tools known in the artmay be able to measure both the 14-MeV elastic scattering cross section,thermal scattering cross section and sigma.

Depending on the existing knowledge or user assumptions, users can inputthe matrix cross section Σ_(matrix) and fluid cross section Σ_(fluid),then solve for the porosity Φ from the measured total cross sectionΣ_(total) as indicated in Eq. 6.

The user can input a value for gas cross section Σ_(gas) additionallythen to solve for both porosity Φ and gas saturation S_(gas) based onEq. 7. In this case, the user needs two independent measurements becausethere are two unknowns. At least one of the two independent measurementsis one of the two neutron cross sections. Others can be another neutroncross section or another type of measurement, such as density, sigma,natural gamma ray, resistivity, and so on.

Additionally, the user can input the oil cross section to solve forporosity Φ, gas saturation S_(gas) and oil saturation S_(oil) based onEq. 8. In this case, the user needs three independent measurementsbecause there are three unknowns. At least one of the three independentmeasurements is one of the two neutron cross sections. The others can bethe other neutron cross sections or another type of measurement, such asdensity, sigma, natural gamma ray, resistivity, and so on.

Of note is that Eq. 6, Eq. 7, and Eq. 8 are all linear functions of thevolume fraction (porosity or saturation). This makes problem solvingvery easy and flexible.

Σ_(total)=(1−φ)·Σ_(matrix)+φ·Σ_(fluid)  (6)

Σ_(total)(1−φ)·Σ_(matrix)+φ·(1−S _(gas))·Σ_(fluid) +φ·S_(gas)·Σ_(gas)  (7)

Σ_(total)(1−φ)·Σ_(matrix)+φ·(1−S _(gas) −S _(oil))·Σ_(water) +φ·S_(gas)·Σ_(gas) +φ·S _(oil)·Σ_(oil)   (8)

Following the same principle, other applications may be based on one (orboth) of the two measured neutron cross sections.

In another embodiments, a new term may be introduced called TNXS, whichstands for thermal neutron cross section. TNXS may be equal to theneutron elastic scattering cross section at thermal energy or atepithermal energy, as explained with reference to the previousembodiments. However, TNXS may also be defined as a weighted linearcombination of the thermal neutron elastic scattering cross section andany other formation bulk property, for example and without limitation,bulk density, thermal neutron capture cross-section (Sigma), atomdensity, macroscopic elastic scattering cross section at 1 eV,moderating power (as described with reference to the previousembodiments). The purpose of introducing the term TNXS is to improve theaccuracy of using determined neutron cross sections to predict neutronporosity. Using the thermal neutron cross section alone to predictneutron porosity is only a first order approximation.

Because TNXS is a linear combination of a number of formation bulkproperties that follow a volumetric mixing law, TNXS follows thevolumetric mixing law as well. TNXS may be used with other availableformation parameter measurements such as bulk density and/or Sigma topredict formation properties such as neutron porosity. If bulk densityand/or Sigma are available, the value of TNXS can be extracted from themeasurements. For example, the detector count rate ratio from thecompensated neutron tool measurement (TNRA) can be written as a functionof TNXS, bulk density and Sigma as indicated in Eq. (9), whichrepresents a possible forward model of the measured quantity TNRA. Theforegoing specific formation parameters used to estimate TNXS are notlimiting; they may be convenient because they may be determined usingmeasurements from certain types of multiple detector pulsed neutron welllogging instruments, thus simplifying the instrumentation needed todetermined TNXS.

The formula to determine TNXS is not limited to linear combinations. Inthe example shown graphically in FIG. 12 the relationship may be afunction fitted to data. The function is shown as Eq. (9), and TNXS inthis example is defined as the thermal elastic scattering cross section.

$\begin{matrix}{{TNRA} = {\exp \left\lbrack {{a_{1} \cdot \left( \frac{1}{{TNXS} + {0.085 \cdot {\log ({Sigma})}}} \right)^{3}} + {a_{2} \cdot \left( \frac{1}{{TNXS} + {0.085 \cdot {\log ({Sigma})}}} \right)^{2}} + {a_{3} \cdot \left( \frac{1}{{TNXS} + {0.085 \cdot {\log ({Sigma})}}} \right)} + a_{4}} \right\rbrack}} & (9)\end{matrix}$

In describing the previous embodiments, it was shown that the netinelastic gamma ray measurement from a pulsed neutron logging instrumentmay be predicted mainly by the elastic scattering cross section at thesource energy (which may be 14 MeV but is not so limited). Similarly tothe introduction of the term TNXS, in the present embodiment a new termcalled FNXS may be introduced. FNXS represents the fast neutron crosssection. FNXS may be defined as a weighted linear combination of theelastic scattering cross section at the neutron source energy (e.g., 14MeV) with any other formation bulk properties, including for example andwithout limitation, formation bulk density, Sigma, atom density,macroscopic inelastic scattering cross section at a particular neutronenergy or integrated over a particular neutron energy range. The purposeof introducing the FNXS term is to improve the accuracy of using thehigh energy neutron cross section to predict the fast neutronmeasurement. Using the neutron source energy (e.g., 14 MeV) elasticneutron cross section alone to predict the results of the fast neutronmeasurement is only a first order approximation.

FIG. 13 and FIG. 14 show an example for FNXS. FIG. 13 shows thelogarithm of modeled inelastic gamma ray count rate as a function of the14-MeV macroscopic elastic scattering cross section for variousformation conditions. FIG. 13 shows modeled inelastic gamma ray eventsin a gamma ray detector of a typical pulsed neutron logging instrumentas a function of the 14-MeV neutron macroscopic elastic scattering crosssection. The water-filled porosities are 0, 4, 10, 17, 25, 34, 45 and 65p.u., and methane gas (0.1 g/cm³) filled porosities are 0, 4, 10, 17, 25and 34 p.u. As can be observed in FIG. 13, the 14-MeV cross sectiondominates the inelastic measurement, but it is only a first orderapproximation with limitations.

FIG. 14 shows the same modeled data plotted as a function of FNXS, whichis defined by Eq. (10). Essentially, in this case, FNXS is defined as aweighted linear combination of the 14-MeV elastic cross section, the14-MeV inelastic cross section, and the atom density. Compared to theresults shown in FIG. 13, using FNXS may improve the predictionaccuracy, i.e., the accuracy of the forward model.

FNXS=Σ_(@14 MeV) ^(elastic) +a ₁·Σ_(@14 MeV) ^(inelastic) +a₂·ρ_(atom)  (10)

The approach used in Eq. (10) is to determine an expression for aquantity, herein referred to as the effective fast neutron crosssection, which is a linear combination of the volume fractions of eachof the materials in the formation including the fluid, for which the netinelastic count rate is a function of that quantity only. As is wellknown, neutron energy loss due to inelastic reactions is much morecomplicated than the elastic case both because the cross sections canvary dramatically with energy as can the energy loss per interaction.Rather than estimating the effective fast neutron cross section by usingdensity and cross sections selected at a particular energy, an alternateapproach is to derive the best effective fast neutron cross section foreach material by optimizing these cross sections to fit the modeledand/or measured count rates over a data set containing the materials ofinterest. In particular let:

c_(i)=Net inelastic count rate at a given neutron output for a formationcase iρ_(ij)=Atom number density of element j in formation case iFNXS_(i)=Effective macroscopic fast neutron cross section for formationcase ia_(j)=Effective microscopic fast neutron cross section for element jƒ(FNXS)=a function that provides the net inelastic count rate given theeffective fast neutron cross section, e.g.

c=ƒ(FNXS)=b·e ^(a·FNXS)  (11)

By using the definitions of macroscopic and microscopic cross section,one may obtain the expression

$\begin{matrix}{{FNXS}_{i} = {\sum\limits_{j}\; {\rho_{ij} \cdot a_{j}}}} & (12)\end{matrix}$

where a_(j) (and hence FNXS_(i)) may be determined by modeling ormeasuring a preferably wide range of formation cases incorporating theminerals and fluids (and hence elements) commonly found in oil welllogging and minimizing a cost function expression such as

$\begin{matrix}{\sum\limits_{i}\; \left( {c_{i} - {f\left( {FNXS}_{i} \right)}} \right)^{2}} & (13)\end{matrix}$

Once the effective microscopic fast neutron cross section is obtainedfor common elements in earth, it is possible to compute the effectivemacroscopic fast neutron cross section FNXS for various formation usingEq. (13). Since the atom number densities are known functions of thematerial volume fractions alone, Eq. (5) satisfies the linearcombination requirement of the approach noted above and by constructionit may be the most desirable approach given the limitations of using alinear model.

Eqs. (6), (7), and (8) can be generalized as shown in Eq. (14).

$\begin{matrix}{\Sigma = {\sum\limits_{i = 1}^{N}\; {V_{i} \cdot \Sigma_{i}}}} & (14)\end{matrix}$

Where Σ is a measured formation bulk quantity, which can be FNXS, TNXS,Sigma, bulk density, elemental yields, TOC, among other quantities. Theformation can be divided into several parts with the total number equalto N. For examples, one can divide a formation into two parts: rockmineral grains (matrix) and fluid-filled pore space with N=2, as shownin Eq. (6). One can also divide a formation into three parts: rockmatrix, fluid-filled pore space, and gas-filled pore space, with N=3, asshown in Eq. (7). One can divide formation to four parts: rock matrix,water-filled pore, oil-filled pore and gas-filled pore with N=4, asshown in Eq. (8). In above examples, one can also divide rock matrixfurther into several minerals such as sandstone, limestone, dolomite,shale, and so on. The fractional volume of each of the parts of theformation is defined as Vi in Eq. (14), and is the unknown to solve. Thesum of the fractional volume is equal to 1 by definition as shown in Eq.(15). Σi is the bulk quantity of each part of the formation, which aretypically available and computed from theoretical values.

$\begin{matrix}{1 = {\sum\limits_{i = 1}^{N}\; V_{i}}} & (15)\end{matrix}$

Eqs. (14) and (15) are linear equations for unknown variables Vi, thusthey can be solved using simple linear algebra or any available linearsolver application. If for example, FNXS, TNXS, and Sigma are measuredand available, one can obtain 3 equations (one Eq. (14) for eachmeasured bulk quantity). Thus, there are 4 equations available includingEq. (15). Thus as many as 4 unknown volumes can be solved, which meansN≦4. In this case, one can solve the volumes of, for example quartzmatrix, shale, fresh water, and gas. The total porosity can bedetermined to be equal to the sum of the volumes of fresh water and gas.The gas saturation can be determined to be equal to the volume of gasdivided by the total porosity.

In other examples, one can add one or more of the following: condensategas, CO₂ gas, steam, air, light oil, kerogen, into the linear model andsolve the corresponding volumes using measured TNXS and/or FNXS withother measured bulk quantities.

FIG. 15 shows a flow chart of an example technique for determining FNXS.At 302, inelastic gamma ray measurements may be made at one or morespaced apart locations from a neutron source, e.g., a pulsed neutronsource as shown in FIG. 1A. At 300, other formation parametermeasurements may be obtained, for example and without limitation, bulkdensity and Sigma. At 304, a forward model may be defined, such asexplained with reference to Eq. (11). A value of FNXS may be determined,at 306, from the defined relationship at 304.

FIG. 16 shows a flow chart of an example technique for determining TNXS.At 310, formation parameter measurements, including without limitationbulk density and Sigma may be obtained. At 312, thermal neutronmeasurements, such as made by detecting capture gamma rays (see FIG. 1A)at two or more spaced apart locations from the neutron source may beobtained. At 314, the thermal neutron measurements and formationparameter measurements may be entered into an empirically determinedrelationship for TNXS with reference to the thermal neutron measurementsand the formation parameter measurements as shown in Eq. (9). TNXS maybe determined from the defined relationship at 316.

FIG. 17 shows a flow chart of using either FNXS or TNXS to determineformation porosity and content of the porosity. At 330, formationparameter measurements including but not limited to bulk density andSigma may be obtained. At 332, either FNXS or TNXS obtained as explainedwith reference to FIGS. 15 and 16, respectively, may be obtained. At 334TNXS or FNXS or both, may be entered into a volumetric calculationcomprising a system of linear equations based on Eqs. (14) and (15).Solution to the system of linear equations enables determining volumesof each separate formation component, at 336, and as explained abovewith reference to Eqs. (14) and (15). In some embodiments, if both FNXSand TNXS are used, a volume fraction of at least one formation componentmay be determined without the need to use an additional measurement of aformation parameter.

A possible benefit of using bulk density and/or Sigma for the additionalpetrophysical parameter measurements is that such measurements may beobtained by using an instrument such as shown in and explained withreference to FIG. 1D. It will be appreciated by those skilled in the artthat the processes described with reference to FIGS. 15, 16 and 17 maybe performed in a computer system such as the one explained withreference to FIG. 1C, or in the recording unit shown at 70 in FIG. 1A orthe recording unit shown at 250 in FIG. 1B.

Methods according to the present disclosure may enable determiningformation properties such as porosity and fluid content in the rock porespaces with more accuracy and less computational cost than prior methodsusing pulsed neutron measurements.

While the invention has been described with respect to a limited numberof embodiments, those skilled in the art, having benefit of thisdisclosure, will appreciate that other embodiments can be devised whichdo not depart from the scope of the invention as disclosed herein.Accordingly, the scope of the invention should be limited only by theattached claims.

What is claimed is:
 1. A method for determining a fractional volume ofat least one component of a formation, comprising: entering into acomputer a number of detected radiation events resulting from impartingneutrons into the formation at an energy level of at least 1 millionelectron volts (MeV), the detected radiation events corresponding to atleast one of an energy level of the imparted neutrons, and thermal orepithermal energy neutrons; and at least one of, (i) in the computer,using a fast neutron cross-section and a thermal neutron cross-sectiondetermined from the detected radiation events to determine a fractionalvolume of the at least one component of the formation, and (ii) enteringinto the computer a measurement of at least one additional petrophysicalparameter and in the computer using (a) the measurement of the at leastone petrophysical parameters and (b) at least one of the fast neutroncross-section and the thermal neutron cross-section to determine thefractional volume of the at least one component of the formation.
 2. Themethod of claim 1 wherein the at least one additional petrophysicalparameter comprises bulk density.
 3. The method of claim 1 wherein theat least one additional petrophysical parameter comprises thermalneutron capture cross-section (Sigma).
 4. The method of claim 1 whereinthe imparting neutrons comprises operating a pulsed neutron source. 5.The method of claim 4 wherein an energy of neutrons emitted by thepulsed neutron source is approximately 14 MeV.
 6. The method of claim 1wherein the detected radiation events comprise gamma rays resulting frominteraction of the imparted neutrons with the formation.
 7. The methodof claim 6 wherein the gamma rays comprise inelastic scattered gammarays.
 8. The method of claim 6 wherein the gamma rays comprise capturegamma rays.
 9. The method of claim 1 wherein the thermal neutroncross-section is determined using an empirical relationship betweennumbers of detected thermal neutron radiation events and at least oneother petrophysical parameter.
 10. The method of claim 9 wherein thethermal neutron radiation events are detected at two different distancesfrom a position of the imparting neutrons and the empirical relationshipwith the at least one other petrophysical parameter is with a ratio ofnumbers of thermal neutron radiation events at each of the two differentdistances.
 11. The method of claim 10 wherein the thermal neutronradiation events comprise capture gamma rays.
 12. The method of claim 1wherein the fast neutron cross-section is determined as a weightedlinear combination of a 14-MeV neutron elastic cross section, a 14-MeVneutron inelastic cross section, and an atom density of a formationmaterial.
 13. The method of claim 1 wherein the component of theformation comprises at least one of rock matrix, porosity, gas filledporosity and liquid filled porosity.
 14. A method for well logging,comprising: moving a well logging instrument along a wellbore drilledthrough subsurface formations, the well logging instrument comprising asource of neutrons having emitted energy of at least million electronvolts (MeV) and at least two radiation detectors spaced apart from thesource at different distances along the instrument; imparting neutronsfrom the source into formations adjacent to the well logging instrument;detecting neutron induced radiation events at each of the two detectors;entering into a computer a number of the detected radiation events, thedetected radiation events corresponding to at least one of an energylevel of the imparted neutrons, and thermal or epithermal energyneutrons; and at least one of, (i) in the computer, using a fast neutroncross-section and a thermal neutron cross-section determined from thedetected radiation events to determine a fractional volume of the atleast one component of the formation, and (ii) entering into thecomputer a measurement of at least one additional petrophysicalparameter and in the computer using (a) the measurement of the at leastone petrophysical parameters and (b) at least one of the fast neutroncross-section and the thermal neutron cross-section to determine thefractional volume of the at least one component of the formation. 15.The method of claim 14 wherein the at least one additional petrophysicalparameter comprises bulk density.
 16. The method of claim 14 wherein theat least one additional petrophysical parameter comprises thermalneutron capture cross-section (Sigma).
 17. The method of claim 14wherein the neutron source comprises a pulsed neutron source.
 18. Themethod of claim 17 wherein an energy of neutrons emitted by the pulsedneutron source is approximately 14 MeV.
 19. The method of claim 17wherein the detected radiation events comprise gamma rays resulting frominteraction of the imparted neutrons with the formations.
 20. The methodof claim 19 wherein the gamma rays comprise inelastic scattered gammarays.
 21. The method of claim 19 wherein the gamma rays comprise capturegamma rays.
 22. The method of claim 14 wherein the thermal neutroncross-section is determined using an empirical relationship betweennumbers of detected thermal neutron radiation events and at least oneother petrophysical parameter.
 23. The method of claim 22 wherein theempirical relationship with the at least one other petrophysicalparameter is with a ratio of numbers of thermal neutron radiation eventsat each of the two different distances.
 24. The method of claim 23wherein the thermal neutron radiation events comprise capture gammarays.
 25. The method of claim 14 wherein the fast neutron cross-sectionis determined as a weighted linear combination of a 14-MeV neutronelastic cross section, a 14-MeV neutron inelastic cross section, and anatom density of a formation material.
 26. The method of claim 14 whereinthe component of the formation comprises at least one of rock matrix,porosity, gas filled porosity and liquid filled porosity.
 27. The methodof claim 14 wherein the moving the well logging instrument comprisesmoving an electrical cable in the wellbore, the well logging instrumentconnected to the electrical cable.
 28. The method of claim 14 whereinthe moving the well logging instrument comprises moving a drill stringalong the wellbore, the well logging instrument disposed in a part ofthe drill string.